US4488598A - Steam, noncondensable gas and foam for steam and distillation drive _in subsurface petroleum production - Google Patents
Steam, noncondensable gas and foam for steam and distillation drive _in subsurface petroleum production Download PDFInfo
- Publication number
- US4488598A US4488598A US06/476,642 US47664283A US4488598A US 4488598 A US4488598 A US 4488598A US 47664283 A US47664283 A US 47664283A US 4488598 A US4488598 A US 4488598A
- Authority
- US
- United States
- Prior art keywords
- steam
- formation
- injection
- well
- petroleum
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Expired - Fee Related
Links
- 239000003208 petroleum Substances 0.000 title claims abstract description 26
- 239000006260 foam Substances 0.000 title claims abstract description 20
- 238000004821 distillation Methods 0.000 title claims abstract description 17
- 238000004519 manufacturing process Methods 0.000 title claims abstract description 16
- 238000002347 injection Methods 0.000 claims abstract description 45
- 239000007924 injection Substances 0.000 claims abstract description 45
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 44
- 238000000034 method Methods 0.000 claims abstract description 36
- 239000000463 material Substances 0.000 claims abstract description 13
- 239000012530 fluid Substances 0.000 claims abstract description 4
- 238000001256 steam distillation Methods 0.000 claims description 15
- 238000010793 Steam injection (oil industry) Methods 0.000 claims description 11
- 238000010438 heat treatment Methods 0.000 claims description 8
- 239000004094 surface-active agent Substances 0.000 claims description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 7
- 238000012544 monitoring process Methods 0.000 claims 3
- 230000000977 initiatory effect Effects 0.000 claims 1
- 238000005755 formation reaction Methods 0.000 abstract description 33
- 238000011084 recovery Methods 0.000 abstract description 15
- 230000004888 barrier function Effects 0.000 abstract 1
- 239000007789 gas Substances 0.000 description 57
- 239000003921 oil Substances 0.000 description 28
- 230000008569 process Effects 0.000 description 17
- FFBHFFJDDLITSX-UHFFFAOYSA-N benzyl N-[2-hydroxy-4-(3-oxomorpholin-4-yl)phenyl]carbamate Chemical compound OC1=C(NC(=O)OCC2=CC=CC=C2)C=CC(=C1)N1CCOCC1=O FFBHFFJDDLITSX-UHFFFAOYSA-N 0.000 description 14
- 230000007246 mechanism Effects 0.000 description 8
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 8
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 239000000203 mixture Substances 0.000 description 6
- OFBQJSOFQDEBGM-UHFFFAOYSA-N n-pentane Natural products CCCCC OFBQJSOFQDEBGM-UHFFFAOYSA-N 0.000 description 6
- 238000010795 Steam Flooding Methods 0.000 description 5
- 239000010779 crude oil Substances 0.000 description 5
- 229930195733 hydrocarbon Natural products 0.000 description 5
- 150000002430 hydrocarbons Chemical class 0.000 description 5
- 230000004048 modification Effects 0.000 description 5
- 238000012986 modification Methods 0.000 description 5
- ATUOYWHBWRKTHZ-UHFFFAOYSA-N Propane Chemical compound CCC ATUOYWHBWRKTHZ-UHFFFAOYSA-N 0.000 description 4
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 description 3
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 description 3
- 239000003546 flue gas Substances 0.000 description 3
- 238000005187 foaming Methods 0.000 description 3
- 229910052757 nitrogen Inorganic materials 0.000 description 3
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 239000001273 butane Substances 0.000 description 2
- 230000005465 channeling Effects 0.000 description 2
- 239000000839 emulsion Substances 0.000 description 2
- 230000005484 gravity Effects 0.000 description 2
- IJDNQMDRQITEOD-UHFFFAOYSA-N n-butane Chemical compound CCCC IJDNQMDRQITEOD-UHFFFAOYSA-N 0.000 description 2
- 229920000642 polymer Polymers 0.000 description 2
- 239000001294 propane Substances 0.000 description 2
- 238000004064 recycling Methods 0.000 description 2
- 238000007630 basic procedure Methods 0.000 description 1
- 238000009835 boiling Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 239000011236 particulate material Substances 0.000 description 1
- 230000000149 penetrating effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000004525 petroleum distillation Methods 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 238000013517 stratification Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 239000012808 vapor phase Substances 0.000 description 1
- 238000009834 vaporization Methods 0.000 description 1
- 230000008016 vaporization Effects 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/166—Injecting a gaseous medium; Injecting a gaseous medium and a liquid medium
- E21B43/168—Injecting a gaseous medium
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
- E21B43/40—Separation associated with re-injection of separated materials
Definitions
- This invention relates to a method of recovering crude petroleum from subsurface earth formations, and more particularly, to a method of recovering crude petroleum from the subsurface by a steam and gas distillation drive process.
- the method may be used in primary recovery processes in highly viscous petroleum deposits as well as in secondary recovery processes where lighter crudes have already been recovered.
- a steam distillation recovery process is expected to recover more residual oil than a waterflood process because the steam distillation process (1) reduces oil viscosity, which improves oil mobility; (2) thermally expands the oil; (3) establishes gas drive from the steam vapor phase; and (4) distills the lighter oil components.
- U.S. Pat. No. 4,086,964 describes the use of a foam-forming mixture of steam, noncondensable gas and surfactant injected into a steam channel in an oil reservoir in which stratification of the rock permeability is insufficient to confine steam within the permeable strata.
- the noncondensable gas added to the foam and steam is in very low concentration to stabilize the foam.
- the gas is included in fractions of a mole percent in the foam and the foam is intended to resist the flow of steam through the oil-depleted steam zone, thereby diverting the steam into undepleted zones.
- the novelty of the process described herein lies in the effect that vapor volume and temperature have on distillation of the reservoir crude.
- the combination of injection of high temperature steam for the steam distillation of the reservoir crude to produce a distillate bank with the injection of noncondensable gas increases the vapor volume and further enhances distillation of the reservoir crude.
- a suitable foaming surfactant is injected with the gas to create a foam block in the swept zone and divert the gas or steam gas combination into unswept zones of the reservoir.
- Other diverting processes may also be used.
- the noncondensable gas may consist of, but not be limited to, one or more of the following gases: nitrogen, air, CO 2 , flue gas, hydrocarbon gas (i.e., methane, ethane, propane, butane, pentane, and any hydrocarbons that are gaseous at steamflood conditions).
- the object of the present invention is to improve the recovery of crude oil from a subsurface reservoir by the combination of processes of steam injection to accomplish formation heating and petroleum distillation with the injection of a noncondensable gas to further enhance the petroleum heating and distillation plus the introduction of a foam block to direct the heat distilled petroleum, noncondensable gas and steam to the unswept portions of the reservoir where recoverable crude petroleum is expected to reside.
- FIG. 1 is a block diagram of the injection and production elements useful in performing the method of the present invention.
- FIGS. 2A, 2B and 2C are cross-sectional views through a subsurface petroleum-containing reservoir illustrating in time sequence the method of the present invention.
- a plurality of materials are injected singly and in combinations into a subsurface petroleum-containing reservoir to cause the petroleum to move into a producer well.
- the earth formation 10 has a subsurface petroleum-containing formation 12 with an injection well 14 and a producing well 16 passing through the formation to the reservoir.
- the wellhead 18 of the injection well 14 has a multipurpose valve 20 connected to it for control of materials injected into the formation through the injection well.
- An injection controller 22 controls the manifold system 20 to control the injection of steam from steam generator 24, the injection of noncondensible gas from source 26, the injection of a foamable surfactant from tank 28, and the overall pressure within the wall is sensed through sensor 30 in accord with the rates of injection of the steam, gas and foam.
- Each of the separate sources of injection materials 24, 26 and 28 is supplied to the manifold 20 through separate pumps 32, 34 and 36.
- the producing well 16 has a wellhead at 40 through which materials produced from the reservoir 12 are pumped with the assistance of pump 42, if needed.
- the produced materials are passed to a separator 44 where at least crude oil, noncondensable gas, and water are separated and supplied to suitable containers 46, 48 and 50, respectively.
- the water container 50 is shown connected to the steam generator 24 to permit recycling of the produced water after cleanup and the noncondensable gas container 48 is shown connected to the gas source 26 to permit recapture and recycling of the injected gas.
- the separator 44 is also capable of separating foam from the materials produced through production well 16 and the foam will collapse in the conventional manner or upon treatment with foam breaking chemicals.
- Temperature sensor 52 and pressure sensor 54 are connected to the production line from the producing well 16 and are intended to represent sensing means for determining the conditions at the wellhead or within the reservoir, whichever is desired.
- Each of the containers 46, 48 and 50 and the sensors 52 and 54 is connected in an operational sense to the injection controller 22 to permit the controller to be informed to the conditions in the container or sensor.
- the materials injected and the condition of the injected materials will be varied in accord with the method of the present invention in response to conditions sensed or occurring at the production well.
- FIG. 1 it is possible to control the separate, sequential or simultaneous injection of steam, noncondensable gas or foamable surfactant at desired pressure and temperature to accomplish the formation sweep illustratively shown in FIGS. 2A, 2B and 2C.
- FIGS. 2A, 2B and 2C FIGS. 2A, 2B and 2C.
- steam is initially injected through injection well 14 penetrating an earth formation into a petroleum containing formation 12.
- the well 14 is perforated at 15 at the lower end of the injection well.
- a combination of noncondensable gas, foamable surfactant and steam is injected through the injection well 14 to produce a foam zone 23 in the depleted portion of the steam zone above the oil-producing steam zone 19.
- the foam zone 23 inhibits the passage of steam directly into the producing well 16 and creates a flow resistance to force the steam and noncondensable gas to produce a continuing distillate bank 17 into the formation 12, thus encouraging an efficient sweep of the formation and production of the crude into the well 16.
- the novelty of the processes described in this disclosure lies mainly in the effect that vapor volume and temperature have on distillation of the crude oil.
- the injection of high temperature steam enhances the distillation of the crude oil and the formation of a distillate bank.
- the injection of a noncondensable gas increases the vapor volume, which also enhances distillation of the crude oil.
- the injection of foam after or with the steam and noncondensable gas assists in the recovery by preventing loss of the steam and gas through depleted zones in the formation.
- One procedure for the steam and gas distillation drive process of the present invention is the following steps:
- a suitable foaming surfactant is injected with the gas to create a foam block in the swept zone and to divert the gas into oil producing unswept zones.
- Other diverting processes may also be used.
- the noncondensable gas may consist of, but not be limited to one or more of the following gases: nitrogen, air, CO 2 , flue gas, hydrocarbon gas (i.e., methane, ethane, propane, butane, pentane, and any hydrocarbons that are gaseous at steamflood conditions).
- a modification of the Process 1 described above includes the following procedures:
- a further modification of the Process 1 described above includes the following procedures:
- the steam and gas distillation drive processes described herein can recover additional oil from a subsurface earth formation above and beyond what would be recovered by conventional steamflooding alone, using the equivalent amount of injected steam.
- the processes described use conventional oil field equipment, including steam generators and gas compressors.
- Foam generators and foaming materials are described in U.S. Pat. Nos. 3,603,398, S. O. Hutchison et al, issued Sept. 7, 1971 for "Method of Placing Particulate Material In An Earth Formation With Foam" and 3,463,231, S. O. Hutchison et al issued Aug. 26, 1969 for "Generation And Use of Foamed Well Circulation Fluids".
Abstract
Description
Claims (3)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US06/476,642 US4488598A (en) | 1983-03-18 | 1983-03-18 | Steam, noncondensable gas and foam for steam and distillation drive _in subsurface petroleum production |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US06/476,642 US4488598A (en) | 1983-03-18 | 1983-03-18 | Steam, noncondensable gas and foam for steam and distillation drive _in subsurface petroleum production |
Publications (1)
Publication Number | Publication Date |
---|---|
US4488598A true US4488598A (en) | 1984-12-18 |
Family
ID=23892667
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US06/476,642 Expired - Fee Related US4488598A (en) | 1983-03-18 | 1983-03-18 | Steam, noncondensable gas and foam for steam and distillation drive _in subsurface petroleum production |
Country Status (1)
Country | Link |
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US (1) | US4488598A (en) |
Cited By (37)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4570711A (en) * | 1984-08-09 | 1986-02-18 | Shell Oil Company | Process for optimizing the noncondensible gas content of an oil-displacing steam-foam-forming mixture |
US4601336A (en) * | 1984-09-17 | 1986-07-22 | Shell Oil Company | Process for selecting a steam foam forming surfactant |
US4607695A (en) * | 1984-02-16 | 1986-08-26 | Mobil Oil Corporation | High sweep efficiency steam drive oil recovery method |
US4703797A (en) * | 1983-12-28 | 1987-11-03 | Cities Service Co. | Sweep improvement in enhanced oil recovery |
US4727489A (en) * | 1986-08-11 | 1988-02-23 | Texaco Inc. | Apparatus for analyzing the annulus effluent of a well |
DE3828736A1 (en) * | 1987-08-26 | 1989-03-09 | Shell Int Research | METHOD FOR PRODUCING OIL |
US4852653A (en) * | 1988-07-06 | 1989-08-01 | Shell Oil Company | Method to obtain rapid build-up of pressure in a steam foam process |
US4953635A (en) * | 1989-07-27 | 1990-09-04 | Chevron Research Company | Method for improving the steam splits in a multiple steam injection process |
US5000263A (en) * | 1989-07-27 | 1991-03-19 | Chevron Research And Technology Company | Method for improving the steam splits in a multiple steam injection process using multiple steam headers |
US5014787A (en) * | 1989-08-16 | 1991-05-14 | Chevron Research Company | Single well injection and production system |
US5031698A (en) * | 1987-08-26 | 1991-07-16 | Shell Oil Company | Steam foam surfactants enriched in alpha olefin disulfonates for enhanced oil recovery |
US5042583A (en) * | 1988-12-30 | 1991-08-27 | Chevron Research And Technology Company | Steam foam drive method for enhanced oil recovery |
US5056596A (en) * | 1988-08-05 | 1991-10-15 | Alberta Oil Sands Technology And Research Authority | Recovery of bitumen or heavy oil in situ by injection of hot water of low quality steam plus caustic and carbon dioxide |
US5056597A (en) * | 1989-07-27 | 1991-10-15 | Chevron Research And Technology Company | Method for improving the steam splits in a multiple steam injection process using multiple steam headers |
US5131471A (en) * | 1989-08-16 | 1992-07-21 | Chevron Research And Technology Company | Single well injection and production system |
US5193617A (en) * | 1991-07-22 | 1993-03-16 | Chevron Research And Technology Company | Micro-slug injection of surfactants in an enhanced oil recovery process |
US5390740A (en) * | 1993-12-17 | 1995-02-21 | Texaco Inc. | Method and apparatus to recycle production well casing vapor |
WO1998050680A2 (en) * | 1997-05-02 | 1998-11-12 | Baker Hughes Incorporated | Monitoring of downhole parameters and tools utilizing fiber optics |
WO1999002819A1 (en) * | 1997-07-09 | 1999-01-21 | Baker Hughes Incorporated | Computer controlled injection wells |
US6244341B1 (en) | 1999-06-10 | 2001-06-12 | Nitrogen Oil Recovery Systems Llc | Huff and puff process utilizing nitrogen gas |
US6281489B1 (en) * | 1997-05-02 | 2001-08-28 | Baker Hughes Incorporated | Monitoring of downhole parameters and tools utilizing fiber optics |
US20040043501A1 (en) * | 1997-05-02 | 2004-03-04 | Baker Hughes Incorporated | Monitoring of downhole parameters and chemical injection utilizing fiber optics |
US20040065439A1 (en) * | 1997-05-02 | 2004-04-08 | Baker Hughes Incorporated | Wellbores utilizing fiber optic-based sensors and operating devices |
US6942037B1 (en) * | 2002-08-15 | 2005-09-13 | Clariant Finance (Bvi) Limited | Process for mitigation of wellbore contaminants |
WO2008087154A1 (en) * | 2007-01-19 | 2008-07-24 | L'air Liquide Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude | Process and apparatus for enhanced hydrocarbon recovery |
US20110073302A1 (en) * | 2008-09-26 | 2011-03-31 | N-Solv Corporation | Method of controlling growth and heat loss of an in situ gravity draining chamber formed with a condensing solvent process |
CN101576248B (en) * | 2009-06-04 | 2011-08-24 | 重庆新仪自控系统工程有限公司 | Steam-injection boiler optimization running control system |
US20110226473A1 (en) * | 2010-03-18 | 2011-09-22 | Kaminsky Robert D | Deep Steam Injection Systems and Methods |
US20140216739A1 (en) * | 2013-01-08 | 2014-08-07 | Conocophillips Company | Heat scavenging method for thermal recovery process |
CN104265273A (en) * | 2014-09-22 | 2015-01-07 | 中国石油大学(华东) | Testing device and testing method for horizontal well subsection well completion inflow |
US20150159476A1 (en) * | 2013-12-11 | 2015-06-11 | Conocophillips Company | Oil recovery with insulating composition |
CN105064962A (en) * | 2015-06-30 | 2015-11-18 | 中国石油化工股份有限公司 | Oil recovery method for restraining thickened oil thermal recovery edge water propulsion by means of nitrogen foam |
US20170247991A1 (en) * | 2016-02-29 | 2017-08-31 | Ge Energy Oilfield Technology, Inc. | Steam Injection Monitoring, Control and Optimization Using Near-Wellhead Sensors |
US10246979B2 (en) | 2014-03-28 | 2019-04-02 | Suncor Energy Inc. | Remote steam generation and water-hydrocarbon separation in steam-assisted gravity drainage operations |
US10851630B2 (en) | 2016-09-28 | 2020-12-01 | Suncor Energy Inc. | Production of hydrocarbon using direct-contact steam generation |
US11578712B1 (en) * | 2021-09-02 | 2023-02-14 | RheoVest, LLC | Method for pumping foamed fluids into a well bore or subterranean formation |
US20230121121A1 (en) * | 2021-10-19 | 2023-04-20 | Saudi Arabian Oil Company | Nonmetallic downhole check valve to improve power water injector well safety and reliability |
Citations (6)
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US3412794A (en) * | 1966-11-23 | 1968-11-26 | Phillips Petroleum Co | Production of oil by steam flood |
US4086964A (en) * | 1977-05-27 | 1978-05-02 | Shell Oil Company | Steam-channel-expanding steam foam drive |
US4099568A (en) * | 1974-02-15 | 1978-07-11 | Texaco Inc. | Method for recovering viscous petroleum |
US4161217A (en) * | 1978-05-08 | 1979-07-17 | Shell Oil Company | Hot water foam oil production process |
US4324291A (en) * | 1980-04-28 | 1982-04-13 | Texaco Inc. | Viscous oil recovery method |
US4393937A (en) * | 1981-03-25 | 1983-07-19 | Shell Oil Company | Olefin sulfonate-improved steam foam drive |
-
1983
- 1983-03-18 US US06/476,642 patent/US4488598A/en not_active Expired - Fee Related
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
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US3412794A (en) * | 1966-11-23 | 1968-11-26 | Phillips Petroleum Co | Production of oil by steam flood |
US4099568A (en) * | 1974-02-15 | 1978-07-11 | Texaco Inc. | Method for recovering viscous petroleum |
US4086964A (en) * | 1977-05-27 | 1978-05-02 | Shell Oil Company | Steam-channel-expanding steam foam drive |
US4161217A (en) * | 1978-05-08 | 1979-07-17 | Shell Oil Company | Hot water foam oil production process |
US4324291A (en) * | 1980-04-28 | 1982-04-13 | Texaco Inc. | Viscous oil recovery method |
US4393937A (en) * | 1981-03-25 | 1983-07-19 | Shell Oil Company | Olefin sulfonate-improved steam foam drive |
Cited By (68)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4703797A (en) * | 1983-12-28 | 1987-11-03 | Cities Service Co. | Sweep improvement in enhanced oil recovery |
US4607695A (en) * | 1984-02-16 | 1986-08-26 | Mobil Oil Corporation | High sweep efficiency steam drive oil recovery method |
US4570711A (en) * | 1984-08-09 | 1986-02-18 | Shell Oil Company | Process for optimizing the noncondensible gas content of an oil-displacing steam-foam-forming mixture |
US4601336A (en) * | 1984-09-17 | 1986-07-22 | Shell Oil Company | Process for selecting a steam foam forming surfactant |
US4727489A (en) * | 1986-08-11 | 1988-02-23 | Texaco Inc. | Apparatus for analyzing the annulus effluent of a well |
US4957646A (en) * | 1987-08-26 | 1990-09-18 | Shell Oil Company | Steam foam surfactants enriched in alpha olefin disulfonates for enhanced oil recovery |
DE3828736A1 (en) * | 1987-08-26 | 1989-03-09 | Shell Int Research | METHOD FOR PRODUCING OIL |
US5031698A (en) * | 1987-08-26 | 1991-07-16 | Shell Oil Company | Steam foam surfactants enriched in alpha olefin disulfonates for enhanced oil recovery |
US4852653A (en) * | 1988-07-06 | 1989-08-01 | Shell Oil Company | Method to obtain rapid build-up of pressure in a steam foam process |
US5056596A (en) * | 1988-08-05 | 1991-10-15 | Alberta Oil Sands Technology And Research Authority | Recovery of bitumen or heavy oil in situ by injection of hot water of low quality steam plus caustic and carbon dioxide |
US5042583A (en) * | 1988-12-30 | 1991-08-27 | Chevron Research And Technology Company | Steam foam drive method for enhanced oil recovery |
US4953635A (en) * | 1989-07-27 | 1990-09-04 | Chevron Research Company | Method for improving the steam splits in a multiple steam injection process |
US5000263A (en) * | 1989-07-27 | 1991-03-19 | Chevron Research And Technology Company | Method for improving the steam splits in a multiple steam injection process using multiple steam headers |
US5056597A (en) * | 1989-07-27 | 1991-10-15 | Chevron Research And Technology Company | Method for improving the steam splits in a multiple steam injection process using multiple steam headers |
US5014787A (en) * | 1989-08-16 | 1991-05-14 | Chevron Research Company | Single well injection and production system |
US5131471A (en) * | 1989-08-16 | 1992-07-21 | Chevron Research And Technology Company | Single well injection and production system |
US5193617A (en) * | 1991-07-22 | 1993-03-16 | Chevron Research And Technology Company | Micro-slug injection of surfactants in an enhanced oil recovery process |
US5390740A (en) * | 1993-12-17 | 1995-02-21 | Texaco Inc. | Method and apparatus to recycle production well casing vapor |
WO1998050680A2 (en) * | 1997-05-02 | 1998-11-12 | Baker Hughes Incorporated | Monitoring of downhole parameters and tools utilizing fiber optics |
US20040043501A1 (en) * | 1997-05-02 | 2004-03-04 | Baker Hughes Incorporated | Monitoring of downhole parameters and chemical injection utilizing fiber optics |
WO1998050680A3 (en) * | 1997-05-02 | 1999-02-04 | Baker Hughes Inc | Monitoring of downhole parameters and tools utilizing fiber optics |
GB2339902A (en) * | 1997-05-02 | 2000-02-09 | Baker Hughes Inc | Monitoring of downhole parameters and tools utilizing fiber optics |
US7201221B2 (en) | 1997-05-02 | 2007-04-10 | Baker Hughes Incorporated | Wellbores utilizing fiber optic-based sensors and operating devices |
US20060272809A1 (en) * | 1997-05-02 | 2006-12-07 | Baker Hughes Incorporated | Wellbores utilizing fiber optic-based sensors and operating devices |
US6268911B1 (en) | 1997-05-02 | 2001-07-31 | Baker Hughes Incorporated | Monitoring of downhole parameters and tools utilizing fiber optics |
US6281489B1 (en) * | 1997-05-02 | 2001-08-28 | Baker Hughes Incorporated | Monitoring of downhole parameters and tools utilizing fiber optics |
GB2364384A (en) * | 1997-05-02 | 2002-01-23 | Baker Hughes Inc | Enhancing hydrocarbon production by controlling flow according to parameter sensed downhole |
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